CN111561298B - Marine natural gas hydrate reservoir simulation temperature control system and use method - Google Patents
Marine natural gas hydrate reservoir simulation temperature control system and use method Download PDFInfo
- Publication number
- CN111561298B CN111561298B CN202010223941.7A CN202010223941A CN111561298B CN 111561298 B CN111561298 B CN 111561298B CN 202010223941 A CN202010223941 A CN 202010223941A CN 111561298 B CN111561298 B CN 111561298B
- Authority
- CN
- China
- Prior art keywords
- simulation
- natural gas
- gas hydrate
- temperature control
- heat exchange
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000004088 simulation Methods 0.000 title claims abstract description 166
- NMJORVOYSJLJGU-UHFFFAOYSA-N methane clathrate Chemical compound C.C.C.C.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O NMJORVOYSJLJGU-UHFFFAOYSA-N 0.000 title claims abstract description 118
- 238000000034 method Methods 0.000 title claims abstract description 27
- 238000012545 processing Methods 0.000 claims abstract description 30
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 82
- 239000007788 liquid Substances 0.000 claims description 78
- 238000010438 heat treatment Methods 0.000 claims description 27
- 238000001816 cooling Methods 0.000 claims description 24
- 239000007789 gas Substances 0.000 claims description 19
- 230000008569 process Effects 0.000 claims description 19
- 238000003860 storage Methods 0.000 claims description 19
- 238000000354 decomposition reaction Methods 0.000 claims description 12
- 238000009413 insulation Methods 0.000 claims description 10
- 238000002347 injection Methods 0.000 claims description 9
- 239000007924 injection Substances 0.000 claims description 9
- 238000012546 transfer Methods 0.000 claims description 6
- 238000007599 discharging Methods 0.000 claims description 3
- 238000005086 pumping Methods 0.000 claims description 3
- 238000011160 research Methods 0.000 abstract description 9
- 230000008859 change Effects 0.000 abstract description 3
- 230000002457 bidirectional effect Effects 0.000 abstract description 2
- 239000003507 refrigerant Substances 0.000 description 10
- 238000009826 distribution Methods 0.000 description 8
- 238000005516 engineering process Methods 0.000 description 6
- 238000005057 refrigeration Methods 0.000 description 6
- 238000002156 mixing Methods 0.000 description 4
- 230000009977 dual effect Effects 0.000 description 3
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 2
- 238000009529 body temperature measurement Methods 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005485 electric heating Methods 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 230000006870 function Effects 0.000 description 2
- 230000008570 general process Effects 0.000 description 2
- 238000011065 in-situ storage Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000005253 cladding Methods 0.000 description 1
- 238000002485 combustion reaction Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 239000002826 coolant Substances 0.000 description 1
- 239000012809 cooling fluid Substances 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- -1 natural gas hydrates Chemical class 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/001—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells specially adapted for underwater installations
Abstract
The invention provides a marine natural gas hydrate reservoir simulation temperature control system, which comprises a simulation cabin main body, a data acquisition processing unit, an in-cabin temperature control unit and an out-cabin temperature control unit arranged outside a simulation cabin of the simulation cabin main body, wherein each simulation layer in the simulation cabin main body is respectively connected with the in-cabin temperature control unit, and the data acquisition processing unit is respectively connected with the out-cabin temperature control unit and the in-cabin temperature control unit; also provides a using method of the marine natural gas hydrate reservoir simulation temperature control system, which comprises the following steps: s1, simulating a natural gas hydrate reservoir environment; s2, decomposing the natural gas hydrate reservoir. The invention effectively combines the annular wall temperature control and the internal temperature control, implements bidirectional regulation and control on the temperature environment of the natural gas hydrate reservoir, can effectively realize deep sea temperature environment simulation and temperature change regulation of the large-scale natural gas hydrate reservoir within required time, and provides sufficient foundation and convenience for the research of the natural gas hydrate reservoir environment.
Description
Technical Field
The invention relates to the technical field of ocean engineering, in particular to a marine natural gas hydrate reservoir simulation temperature control system and a using method thereof.
Background
The natural gas hydrate is a crystalline cage-shaped compound formed by water molecules and gas molecules under high-pressure and low-temperature environments, and methane molecules are main gas molecules for forming the natural gas hydrate in nature, so the natural gas hydrate is mostly methane hydrate. The natural gas hydrate is mainly stored in permafrost zones and submarine sediments of deep sea continents and slopes, and the natural gas hydrate is concentrated and stored in the natural environment to form a natural gas hydrate reservoir; because of the advantages of large reserves, wide distribution, high energy density, cleanness and no pollution after combustion and the like, the natural gas hydrate is known as a substitute energy source with the greatest prospect in the 21 st century and is favored by governments and researchers of various countries. The trial production of the marine natural gas hydrate reservoir is successively and successfully carried out in Japan and China, however, the natural gas hydrate is different from the conventional oil and gas reservoir resources, is endowed in nature in a solid form, and at present, no mature technical means capable of being commercially exploited exists, and the research of an early reliable natural gas hydrate exploitation technology and the fine research of the basic properties of the natural gas hydrate are urgently needed. The large-scale marine natural gas hydrate simulation technology can truly reflect the multiphase flow state in the natural gas hydrate reservoir, and is an important means for scientific research of natural gas hydrates. The temperature control system is a key step for determining whether the large-scale natural gas hydrate simulation technology is reasonable, because the large-scale natural gas hydrate storage simulation system is large in size and large in specific surface area, the temperature control system can provide large heat or cold in a specified time for heating or cooling operation, and the heat transfer mode is effective and accurate.
Disclosure of Invention
The invention provides a system and a method for controlling the simulated temperature of a marine natural gas hydrate reservoir, aiming at solving the problems that the conventional external cladding water bath temperature control technology of the natural gas hydrate simulation technology in the background technology can not meet the requirements of a large-scale natural gas hydrate reservoir simulation system on rapid and uniform temperature reduction and temperature rise due to the fact that the provided heat and cold are limited, and the heat source and the cold source are far away from the center of the large-scale natural gas hydrate reservoir.
In order to solve the technical problems, the invention adopts the technical scheme that: the utility model provides an ocean natural gas hydrate reserves simulation temperature control system, includes the simulation cabin main part, including the upper deposition layer that sets gradually of top-down, natural gas hydrate reservoir and free gas/free water/gas water mixed layer under, still include data acquisition processing unit, under cabin temperature control unit and establish the extravehicular temperature control unit in the simulation cabin main part outside, every simulation position in the simulation cabin main part all is connected with an independence respectively the under cabin temperature control unit, data acquisition processing unit connects respectively extravehicular temperature control unit with the temperature control under cabin unit. Thus, the simulation cabin main body is a common natural gas hydrate simulation cabin with a large size (the inner effective diameter is more than meter level); the simulation cabin main body is mainly used for simulating a large-scale natural gas hydrate reservoir to provide a space environment, is made of a pressure-resistant material, has the function of adjusting the pressure in the cabin to provide a high-pressure environment, constructs a natural gas hydrate geological layer in the simulation cabin main body according to in-situ geological exploration data, and is divided into an uppermost overlying sedimentary layer, a middle natural gas hydrate reservoir layer and a lower free gas/free water/gas-water mixed layer, wherein the lowermost layer possibly exists in one or only one of the three forms of the free gas/free water/gas-water mixed layer, so the lowermost layer also belongs to one layer; because the natural gas hydrate reservoir is generally positioned in a high-pressure low-temperature environment in deep sea, after the high-pressure simulation cabin main body provides high pressure, the temperature control unit outside the cabin in the technical scheme can quickly cool the interior of the high-pressure simulation cabin main body, and can perform constant-temperature circulation control after cooling, so that the natural gas hydrate reservoir can be controlled in a constant high-pressure low-temperature environment to closely simulate the space environment of the natural gas hydrate reservoir, and the research on the space environment of the natural gas hydrate reservoir is facilitated; in addition, the temperature control unit in the simulation cabin can perform auxiliary temperature control on the simulation cabin main body to enable the temperature distribution of the simulation cabin main body to be more uniform, and can also perform heating and temperature rise on each simulation layer position in the simulation cabin main body to simulate the decomposition process of the natural gas hydrate; the data acquisition and processing unit is responsible for data acquisition in the whole system, mainly comprises pressure, temperature and flow data, and presets the amplitude of temperature reduction or temperature rise according to the acquired data after analysis and processing. The whole system is more comprehensive in the aspect of temperature regulation and control, can meet the requirement of rapidly and uniformly cooling or heating, and provides sufficient foundation and convenience for the research of the natural gas hydrate storage environment.
Furthermore, the extravehicular temperature control unit comprises three groups of annular wall water bath systems which are arranged on the outer wall of the simulation cabin main body in a surrounding manner and correspond to each simulation layer of the simulation cabin main body one by one, heat insulation layers which are correspondingly laid outside the three groups of annular wall water bath systems, and liquid heat exchange circulating systems which are correspondingly connected with the annular wall water bath systems one by one. In this way, because the temperature of each simulated horizon of the natural gas hydrate reservoir in the natural environment is different, therefore, the adjustment of each simulation position is separately controlled to simulate the actual geothermal gradient distribution in the simulation environment, the outer wall of each simulation position is provided with a circular wall water bath system in a surrounding way, the circular wall water bath system of each simulation position is connected with a liquid heat exchange circulating system, the circular wall water bath system can be selectively added with secondary refrigerant or heat-carrying agent, generally secondary refrigerant, the secondary refrigerant is cooled through the liquid heat exchange circulating system and then flows for circulation, after being cooled, the secondary refrigerant flows to the annular wall water bath system and then can exchange heat with each simulated layer object reservoir in the cabin, through circulating heat exchange and cooling, and enabling each simulation layer position to be surrounded in a lower-temperature domain, the temperature of each simulation layer position object reservoir in the simulation cabin main body can be quickly and uniformly cooled; when the temperature data acquired by the data acquisition and processing unit exceed the preset value, the power of the liquid heat exchange circulating system is convenient to adjust, the constant temperature control stage is started, the continuous low temperature control is achieved through the continuous flow of the secondary refrigerant in the water bath system, in addition, a heat insulation layer is laid outside the circular wall water bath system, the heat insulation layer can reduce the heat exchange between the water bath system and the outside, the inside of the simulation cabin main body is indirectly subjected to constant temperature control, and the whole simulation cabin main body is positioned in a stable high-pressure low-temperature environment.
Furthermore, the liquid heat exchange circulating system comprises a circulating pump, a first heat exchange refrigerating unit, a first control valve and a second control valve, a liquid outlet of the annular wall water bath system is connected with a liquid pumping port of the circulating pump through the first control valve, a liquid discharging port of the circulating pump is connected with one end of the first heat exchange refrigerating unit, and the other end of the first heat exchange refrigerating unit is connected with a liquid returning port of the annular wall water bath system through the second control valve. Like this, the circulating pump makes the carrier circulation flow in the water bath system, gets back to first heat transfer refrigerating unit after carrying out the heat transfer with the simulation cabin main part and cools down, pumps once more after the cooling and carries out the heat exchange with the simulation cabin main part in the rampart water bath system, so circulation realizes rapid cycle's cooling.
As a preferred scheme, the temperature control unit in the cabin comprises three groups of heat exchange tubes and sixth control valves, a liquid storage tank, a hot water control valve group, a second heat exchange refrigerating unit, a fifth control valve, a liquid injection pump and a first flowmeter are sequentially connected, the three groups of heat exchange tubes are respectively arranged at each simulation layer position in the main body cabin of the simulation cabin, a first flow meter is provided with a liquid inlet of each heat exchange tube, a liquid outlet of each heat exchange tube is commonly connected with one end of the sixth control valve, and the other end of the sixth control valve is connected with a connecting pipeline between the second heat exchange refrigerating unit and the fifth control valve. The temperature control unit in the simulation cabin is directly connected inside the simulation cabin main body and is mainly used for heating and decomposing each simulation layer position in the simulation cabin main body so as to simulate the decomposition process of the natural gas hydrate, the general process is that liquid in the liquid storage tank flows to the second heat exchange refrigeration unit through the hot water control valve group to be heated and then flows into the liquid injection pump, the liquid injection pump is divided into three branch pipelines through the first flowmeter to respectively realize three flow pipelines in the simulation cabin main body, then each heat exchange pipe is reached, the inside of the simulation object reservoir is heated, the heat exchange efficiency is accelerated, the natural gas hydrate reservoir is heated and decomposed, the liquid in each heat exchange pipe flows out of the heat exchange pipe and then converges into the same loop to flow back to the second heat exchange refrigeration unit, and then the liquid can flow circularly and also can flow back to the liquid storage tank; the first flow meter can control the inflow liquid amount of each branch pipeline and carry out flow acquisition so as to achieve the respective control of each simulation layer; the temperature control unit in the cabin can also be used for simulating the cooling of the cabin main body, and in the low-temperature environment simulation process of the large-scale natural gas hydrate storage, the water bath system which only depends on the ring wall is difficult to make the internal temperature be in the low-temperature environment quickly, the second heat exchange refrigerating unit can also carry out the cooling operation, and the heat exchange pipe can also carry out the cooling treatment at each simulation layer position through the cold adding fluid in the internal part, which is equivalent to the internal and external dual temperature control.
Furthermore, hot water control valves includes third control valve and fourth control valve, the third control valve both ends are connected respectively the liquid return port of liquid storage pot with the liquid return port of second heat exchange refrigerating unit, the fourth control valve both ends are connected respectively the liquid outlet of liquid storage pot with the inlet of second heat exchange refrigerating unit. Therefore, liquid in the liquid storage tank flows out through the fourth control valve and flows back through the third control valve, and branch pipeline control is achieved.
As another preferred scheme, the temperature control unit in the cabin comprises three groups of heating pipes, a power supply and a control switch, and the power supply is respectively connected with each heating pipe through the control switch. Therefore, the heating decomposition process in the simulation cabin main body can be directly heated and decomposed in the form of the electric heating pipes, the heating power can be adjusted according to actual needs, and the heating pipes in each simulation layer are independently controlled through the control switch.
Furthermore, the data acquisition and processing unit comprises a data acquisition unit, a central processing unit, a memory and a display, wherein each simulation layer position in the simulation cabin main body is provided with a temperature sensor, a pipeline of each liquid heat exchange circulating system is connected with a second flowmeter, one end of the data acquisition unit is respectively connected with the temperature sensor, the first flowmeter and the second flowmeter, the other end of the data acquisition unit is connected with one end of the central processing unit, and the other end of the central processing unit is respectively connected with the memory and the display. In this way, a plurality of temperature sensors are uniformly distributed in each simulation layer object reservoir in the simulation cabin main body, multipoint temperature measurement is carried out, the accuracy of data is ensured, and the data is transmitted to a data acquisition unit; in addition, the first flowmeter and the second flowmeter can feed back the flowing data of the liquid in the pipeline, the side surface reflects the power of refrigeration or heating, and each unit can be respectively controlled by acquiring, processing, analyzing and displaying each data, so that the natural gas hydrate reservoir environment in the whole simulation cabin main body is positioned in a stable high-pressure low-temperature environment.
Preferably, the heat exchange tube is a snake-shaped heat exchange tube or a tube type heat exchange tube distributed in parallel. Therefore, the snake-shaped heat exchange tube can greatly increase the contact area of the surface of the snake-shaped heat exchange tube and improve the heat exchange efficiency; the tube array type heat exchange tubes which are distributed in parallel and evenly can exchange heat evenly, and have larger contact area, so that the temperature distribution is more even, and the two modes can be adopted.
The use method of the marine natural gas hydrate reservoir simulation temperature control system comprises the following steps:
s1, natural gas hydrate reservoir environment simulation process: in the natural gas hydrate reservoir simulation cabin body constructed in a layered mode, cooling each simulation layer in the simulation cabin body through the extravehicular temperature control unit; when the temperature data received by the data acquisition and processing unit is lower than a preset value, each simulation layer in the simulation cabin main body is respectively subjected to constant temperature control through the extravehicular temperature control unit;
s2, natural gas hydrate reservoir decomposition process: and heating each simulation layer position in the simulation cabin main body through the temperature control unit in the cabin, and heating and decomposing the natural gas hydrate reservoir in the simulation cabin main body.
Therefore, the system of the marine natural gas hydrate reservoir simulation system is prepared in place through system scheduling operation. Three layers of an overlying sedimentary layer, a natural gas hydrate reservoir and an underlying free gas/free water/gas and water mixing layer are constructed in the simulation cabin body in a layering manner; and then starting a temperature environment simulation phase of the natural gas hydrate reservoir. In the process of forming the natural gas hydrate, the natural gas hydrate reservoir is in a high-pressure low-temperature state, and the low-temperature environment of the natural gas hydrate reservoir needs to be simulated. Firstly, according to geological exploration data, the temperature distribution of three layers of a natural gas hydrate reservoir layer, an overlying sedimentary layer and an underlying free gas/free water/gas and water mixing layer is determined. And then determining the refrigerating capacity required to be provided by the extravehicular temperature control unit according to the actual internal effective volume and the environmental temperature conditions of the three simulated layers, determining the power of a refrigerating unit and a heat exchange unit in the annular wall water bath system and the quantity of secondary refrigerant added in the water bath system according to the refrigerating capacity required to be provided by the extravehicular temperature control unit, and determining the thickness of a heat insulation layer required to be laid on the outer wall of the annular wall water bath system and laying the heat insulation layer. The heat exchange rate of the heat exchange tube is calculated through the refrigerating capacity required to be provided by the internal temperature control unit, and the rate and the temperature of the injected liquid are determined according to the heat exchange rate of the heat exchange tube. And when all the parameters are determined, after each system is prepared in place, starting an extravehicular temperature control unit, cooling three different layers of the natural gas hydrate reservoir until the temperatures of the three layers reach set temperature values, and recording the temperatures of each system in real time in the working process of the whole system. When only depending on the water bath system of rampart and being difficult to make every simulation position in the simulation cabin main part be in low temperature environment fast, also can be used for the cooling of simulation cabin main part with the temperature control unit in the cabin, the second heat transfer refrigeration unit in the temperature control unit in the cabin also can carry out the cooling operation, and the heat exchange tube also can carry out the cooling processing at every position through adding cold fluid inside, is equivalent to inside and outside dual control by temperature change.
In the process of decomposing the natural gas hydrate, heat is required to be supplied from the outside to assist the natural gas hydrate decomposition, the temperature control unit in the cabin can provide a heat source, hot water with a set temperature is injected into the heat exchange tube, heat which is transmitted and diffused from the inner source to the outside is supplied in the natural gas hydrate reservoir, and the injection temperature of the hot water is determined according to the decomposition rate of the natural gas hydrate. Meanwhile, the water bath temperature can be gradually increased in the annular wall water bath system, and the situation that the bottom layer supplies heat to the inside of the natural gas hydrate reservoir from the outside is simulated, so that the natural gas hydrate is required to be decomposed.
Compared with the prior art, the beneficial effects are:
1. the invention effectively combines the annular wall temperature control and the internal temperature control, implements bidirectional regulation and control on the temperature environment of the natural gas hydrate reservoir, can effectively realize deep sea temperature environment simulation and temperature change regulation of the large-scale natural gas hydrate reservoir within required time, and provides sufficient foundation and convenience for the research of the natural gas hydrate reservoir environment.
Drawings
FIG. 1 is a schematic diagram of the overall structure of a heat exchange tube of the marine natural gas hydrate reservoir simulation temperature control system of the invention, which is a serpentine heat exchange tube.
FIG. 2 is a schematic diagram of the overall structure of a heat exchange tube of the marine natural gas hydrate reservoir simulation temperature control system of the invention, which is a tube type heat exchange tube.
Detailed Description
The drawings are for illustrative purposes only and are not to be construed as limiting the patent; for the purpose of better illustrating the embodiments, certain features of the drawings may be omitted, enlarged or reduced, and do not represent the size of an actual product; it will be understood by those skilled in the art that certain well-known structures in the drawings and descriptions thereof may be omitted. The positional relationships depicted in the drawings are for illustrative purposes only and are not to be construed as limiting the present patent.
Example 1
As shown in fig. 1, the system for controlling simulated temperature of marine natural gas hydrate reservoir comprises a simulation cabin main body 101, wherein the simulation cabin main body 101 comprises an overlying sedimentary layer 10, a natural gas hydrate reservoir 20 and a underlying free gas/free water/gas-water mixed layer 30 which are sequentially arranged from top to bottom, and further comprises a data acquisition processing unit 40, an in-cabin temperature control unit 60 and an out-cabin temperature control unit 50 arranged outside the simulation cabin main body 101, each simulated layer in the simulation cabin main body 101 is respectively connected with an independent in-cabin temperature control unit 60, and the data acquisition processing unit 40 is respectively connected with the out-cabin temperature control unit 50 and the in-cabin temperature control unit 60. The data acquisition and processing unit 40 comprises a data acquisition unit, a central processing unit, a memory and a display, wherein each simulation layer position in the simulation cabin main body 101 is provided with a temperature sensor 5, a second flowmeter is connected to a pipeline of each liquid heat exchange circulating system 18, one end of the data acquisition unit is connected with the temperature sensor 5, the first flowmeter 12, the second flowmeter and the other end of the data acquisition unit are connected with one end of the central processing unit, and the other end of the central processing unit is connected with the memory and the display.
In this embodiment, the extravehicular temperature control unit 50 includes three sets of annular wall water bath systems 16 surrounding the outer wall of each simulation layer of the simulation cabin body 101, heat insulating layers 17 correspondingly laid outside the three sets of annular wall water bath systems 16, and liquid heat exchange circulation systems 18 connected to the annular wall water bath systems 16 in a one-to-one correspondence manner. The liquid heat exchange circulating system 18 comprises a circulating pump 2, a first heat exchange refrigerating unit 1, a first control valve 3 and a second control valve 4, a liquid outlet of the annular wall water bath system 16 is connected with a liquid pumping port of the circulating pump 2 through the first control valve 3, a liquid discharging port of the circulating pump 2 is connected with one end of the first heat exchange refrigerating unit 1, and the other end of the first heat exchange refrigerating unit 1 is connected with a liquid returning port of the annular wall water bath system 16 through the second control valve 4. The temperature control unit 60 in the cabin comprises three groups of heat exchange tubes 13 and a sixth control valve 14, a liquid storage tank 6, a hot water control valve group, a second heat exchange refrigerating unit 8, a fifth control valve 9, a liquid injection pump 11 and a first flowmeter 12 which are connected in sequence, the three groups of heat exchange tubes 13 are respectively arranged at each simulation layer position in a 101 cabin of the simulation cabin main body, the first flowmeter 12 is respectively provided with a liquid inlet of each heat exchange tube 13, a liquid outlet of each heat exchange tube 13 is jointly connected with one end of the sixth control valve 14, the other end of the sixth control valve 14 is connected with the second heat exchange refrigerating unit 8 and a connecting pipeline between the fifth control valves 9.
In this embodiment, the heat exchange tube 13 is a serpentine heat exchange tube; the hot water control valve group comprises a third control valve 7 and a fourth control valve 15, two ends of the third control valve 7 are respectively connected with a liquid return port of the liquid storage tank 6 and a liquid return port of the second heat exchange refrigerating unit 8, and two ends of the fourth control valve 15 are respectively connected with a liquid outlet of the liquid storage tank 6 and a liquid inlet of the second heat exchange refrigerating unit 8.
The simulation cabin main body 101 is a common natural gas hydrate simulation cabin with a large size; the simulation cabin main body 101 is mainly used for simulating a large-scale natural gas hydrate reservoir to provide a space environment, is made of a pressure-resistant material, has a function of adjusting the pressure in the cabin to provide a high-pressure environment, and according to in-situ geological exploration data, a natural gas hydrate geological layer is constructed in the simulation cabin main body 101 and is divided into an uppermost overlying sedimentary layer 10, a middle natural gas hydrate reservoir layer 20 and a lower free gas/free water/gas-water mixed layer 30, and because the lowest layer possibly exists in one or only one of the three forms of the free gas/free water/gas-water mixed layer 30, the lowest layer also belongs to one layer;
because the temperature of each simulated layer of the natural gas hydrate in the natural environment is different, the regulation of each simulated layer is separately controlled in the simulated environment, the outer wall of each simulated layer is provided with a circular wall water bath system 16 in a surrounding way, the circular wall water bath system 16 of each simulated layer is connected with a liquid heat exchange circulating system 18, the circular wall water bath system 16 can selectively add a coolant or a heat carrying agent, generally a refrigerating medium, the secondary refrigerant is cooled through the liquid heat exchange circulating system 18 and then flows for circulation, after being cooled, the secondary refrigerant flows to the annular wall water bath system 16 and then can exchange heat with each simulation layer object reservoir in the cabin, through circulating heat exchange and cooling, and enabling each simulation layer position to be surrounded in a lower-temperature domain, the temperature of each simulation layer position object reservoir in the simulation cabin main body 101 can be quickly and uniformly cooled; when the temperature data acquired by the data acquisition and processing unit 40 exceeds a preset value, the power of the liquid heat exchange circulating system 18 is adjusted, the constant temperature control stage is started, the continuous low temperature control is achieved through the continuous flow of the secondary refrigerant in the water bath system 16, in addition, a heat insulation layer 17 is laid outside the annular wall water bath system 16, the heat insulation layer 17 can reduce the heat exchange between the water bath system 16 and the outside, the inside of the simulation cabin main body 101 is indirectly subjected to constant temperature control, and the whole simulation cabin main body 101 is positioned in a stable high-pressure low-temperature environment. The circulating pump 2 enables carrier in the water bath system 16 to flow circularly, the carrier returns to the first heat exchange refrigerating unit 1 for cooling after exchanging heat with the simulation cabin main body 101, and the carrier is pumped into the annular wall water bath system 16 again for heat exchange with the simulation cabin main body 101 after cooling, so that the circulation is realized, and the rapid circulation cooling is realized.
In this embodiment, the temperature control unit 60 in the simulation cabin is directly connected to the inside of the simulation cabin main body 101, and is mainly used for heating and decomposing each simulation layer in the simulation cabin main body 101 to simulate the decomposition process of the natural gas hydrate, and the general process is that the liquid in the liquid storage tank 6 flows to the second heat exchange refrigeration unit 8 through the hot water control valve group to be heated up and then flows into the liquid injection pump 11, the liquid injection pump 11 is divided into three branch pipes through the first flowmeter 12 to respectively realize three flow pipelines in the simulation cabin main body 101, and then reaches each heat exchange pipe 13, the serpentine heat exchange pipe 13 can greatly increase the contact area of the surface thereof, and the heat exchange efficiency is improved; heating each simulation layer inside the simulation cabin main body 101 to accelerate the heat exchange efficiency, so that the natural gas hydrate is heated and decomposed, and the liquid in each heat exchange tube 13 flows out of the heat exchange tube 13, then flows into the same loop and flows back to the second heat exchange refrigerating unit 8, and then can flow circularly or flow back to the liquid storage tank 6; the first flow meter 12 can control the amount of inflow liquid of each branch pipe and perform flow collection so as to achieve separate control of each simulation horizon. The liquid in the liquid storage tank 6 flows out through the fourth control valve 15 and flows back through the third control valve 7, so that the branch pipeline control is realized. A plurality of temperature sensors 5 are arranged in each simulation layer position object reservoir in the simulation cabin main body 101, multipoint temperature measurement is carried out, the accuracy of data is guaranteed, and the data are transmitted to a data acquisition unit; in addition, the first flowmeter 12 and the second flowmeter can feed back the data of the liquid flowing in the pipeline, the side surface reflects the power of refrigeration or heating, and each unit can be respectively controlled by acquiring, processing, analyzing and displaying each data, so that the natural gas hydrate reservoir environment in the whole simulation cabin main body 101 is positioned in a stable high-pressure low-temperature environment.
Because the natural gas hydrate reservoir is generally located in a high-pressure low-temperature environment in deep sea, after the high-pressure simulation cabin main body 101 provides high pressure, the temperature inside the high-pressure simulation cabin main body 101 can be rapidly cooled through the extravehicular temperature control unit 50 in the embodiment, and constant-temperature circulation control can be performed after cooling, so that the natural gas hydrate reservoir space environment can be simulated very closely under a constant high-pressure bottom temperature environment, and the research on the natural gas hydrate reservoir space environment is facilitated; in addition, the temperature control unit 60 in the simulation cabin can perform auxiliary temperature control on the simulation cabin main body 101, so that the temperature distribution of the simulation cabin main body 101 is more uniform, and each simulation layer in the simulation cabin main body 101 can be heated to simulate the decomposition process of the natural gas hydrate; the data acquisition and processing unit 40 is responsible for data acquisition in the whole system, mainly pressure, temperature and flow data, and presets the amplitude of temperature reduction or temperature rise according to the acquired data after analysis and processing. The whole system is more comprehensive in the aspect of temperature regulation and control, can meet the requirement of rapidly and uniformly cooling or heating, and provides sufficient foundation and convenience for the research of the natural gas hydrate storage environment.
Example 2
This example is similar to example 1, except that:
the heat exchange tubes in the embodiment are parallel and uniformly distributed tube type heat exchange tubes, the structure of the heat exchange tubes is shown in fig. 2, the parallel and uniformly distributed tube type heat exchange tubes 13 can uniformly exchange heat, and the contact area is large, so that the temperature distribution is more uniform.
Example 3
This example is similar to example 1, except that:
the temperature control unit 60 in the cabin in this embodiment includes three groups of heating pipes, a power supply and a control switch, and the power supply is connected to each heating pipe through the control switch. The heating tube is a serpentine heating tube. The heating decomposition process in the simulation cabin main body 101 can be directly heated and decomposed in the form of an electric heating pipe, the decomposition efficiency is greatly improved, and the heating pipe in each simulation layer is independently controlled through a control switch.
Example 4
The embodiment provides a method for using the marine natural gas hydrate reservoir simulation temperature control system in embodiment 1, which includes the following steps:
s1, natural gas hydrate reservoir environment simulation process: in the natural gas hydrate reservoir simulation cabin main body 101 constructed in a layered manner, each simulation layer position in the simulation cabin main body 101 is cooled through the extravehicular temperature control unit 50; when the temperature data received by the data acquisition and processing unit 40 is lower than a preset value, each simulation layer in the simulation cabin main body 101 is respectively subjected to constant temperature control through the extravehicular temperature control unit 50;
s2, decomposing the natural gas hydrate: each simulation layer in the simulation cabin main body 101 is heated by the temperature control unit 60 in the cabin, and the natural gas hydrate reservoir in the simulation cabin main body is heated and decomposed.
The working process of the whole system is as follows: and (4) preparing each system of the marine natural gas hydrate reservoir simulation system in place through system scheduling operation. Three layers of an overlying sedimentary deposit 10, a natural gas hydrate reservoir 20 and an underlying free gas/free water/gas and water mixing layer are constructed in the simulation cabin body 101 in a layering mode. And then starting a temperature environment simulation phase of the natural gas hydrate reservoir. In the process of forming the natural gas hydrate, the natural gas hydrate reservoir is in a high-pressure low-temperature state, and the low-temperature environment of the natural gas hydrate reservoir needs to be simulated. First, according to geological exploration data, the temperature distribution of three layers of a natural gas hydrate reservoir 20, an overlying sedimentary layer 10 and an underlying free gas/free water/gas and water mixing layer is determined. And then determining the refrigerating capacity required to be provided by the outdoor temperature control unit 50 according to the actual internal effective volume and the environmental temperature conditions of the three simulated layers, determining the power of a refrigerating unit and a heat exchange unit in the surrounding wall water bath system 16 and the amount of secondary refrigerant added in the water bath system 16 according to the refrigerating capacity required to be provided by the outdoor temperature control unit 50, and determining the thickness of the heat insulation layer 17 required to be laid on the outer wall of the surrounding wall water bath system 16 and laying the heat insulation layer 17. The heat exchange rate of the heat exchange tube 13 is calculated through the refrigerating capacity required to be provided by the internal temperature control unit, and the rate and the temperature of the injected liquid are determined according to the heat exchange rate of the heat exchange tube 13. And when all the parameters are determined and all the systems are prepared in place, starting the extravehicular temperature control unit 50 to cool the three different layers of the natural gas hydrate reservoir until the temperatures of the three layers reach the set temperature values. The temperature of each system needs to be recorded in real time in the working process of the whole system. When it is difficult to make each simulation position in the simulation cabin main body be in the low temperature environment fast only by the water bath system 16 of the surrounding wall, the temperature control unit 60 in the cabin can also be used for cooling the simulation cabin main body 101, the second heat exchange refrigerating unit 8 in the temperature control unit 60 in the cabin can also perform cooling operation, and the heat exchange pipe 13 can also perform cooling treatment at each position through cooling fluid inside, which is equivalent to internal and external dual temperature control.
In the process of heating and decomposing the natural gas hydrate reservoir, heat needs to be supplied from the outside to assist the natural gas hydrate to decompose, the temperature control unit 60 in the cabin can supply a heat source, hot water with a set temperature is injected into the heat exchange pipe 13, heat which is transmitted and diffused from the inner source to the outside is supplied in the natural gas hydrate reservoir, and the injection temperature of the hot water is determined according to the decomposition rate and the heat efficiency of the natural gas hydrate. Meanwhile, the water bath temperature can be gradually increased in the annular wall water bath system 16, and the situation that the bottom layer supplies heat to the inside of the natural gas hydrate reservoir from the outside is simulated, so that the natural gas hydrate is required to be decomposed.
It should be understood that the above-described embodiments of the present invention are merely examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. And are neither required nor exhaustive of all embodiments. Any modification, equivalent replacement, and improvement made within the spirit and principle of the present invention should be included in the protection scope of the claims of the present invention.
Claims (8)
1. A simulation temperature control system for an ocean natural gas hydrate reservoir comprises a simulation cabin main body, wherein the simulation cabin main body comprises an overlying sedimentary layer, a natural gas hydrate reservoir layer and a lower free gas/free water/gas-water mixed layer which are sequentially arranged from top to bottom; the under-deck temperature control unit includes three heat exchange tubes of group, sixth control valve, liquid storage pot, hot water control valves, second heat transfer refrigerating unit, fifth control valve, liquid injection pump and the first flowmeter that connects gradually, three heat exchange tubes of group lay respectively every simulation level in simulation cabin main part cabin, the pipe connection is established every to first flowmeter score the inlet of heat exchange tube, every the liquid outlet of heat exchange tube connects jointly the one end of sixth control valve, the other end of sixth control valve is connected the second heat transfer refrigerating unit with on the connecting tube between the fifth control valve.
2. The marine natural gas hydrate reservoir simulation temperature control system as claimed in claim 1, wherein the extravehicular temperature control unit comprises three groups of annular wall water bath systems which are arranged on the outer wall of the simulation cabin body in a surrounding manner and correspond to each simulation layer of the simulation cabin body in a one-to-one manner, heat insulation layers which are correspondingly laid outside the three groups of annular wall water bath systems, and liquid heat exchange circulation systems which are correspondingly connected with each group of annular wall water bath systems in a one-to-one manner.
3. The marine natural gas hydrate reservoir simulation temperature control system according to claim 2, wherein the liquid heat exchange circulation system comprises a circulation pump, a first heat exchange refrigerating unit, a first control valve and a second control valve, a liquid outlet of the annular wall water bath system is connected with a liquid pumping port of the circulation pump through the first control valve, a liquid discharging port of the circulation pump is connected with one end of the first heat exchange refrigerating unit, and the other end of the first heat exchange refrigerating unit is connected with a liquid returning port of the annular wall water bath system through the second control valve.
4. The marine natural gas hydrate reservoir simulation temperature control system according to claim 3, wherein the hot water control valve set comprises a third control valve and a fourth control valve, two ends of the third control valve are respectively connected with a liquid return port of the liquid storage tank and a liquid return port of the second heat exchange refrigerating unit, and two ends of the fourth control valve are respectively connected with a liquid outlet of the liquid storage tank and a liquid inlet of the second heat exchange refrigerating unit.
5. The marine natural gas hydrate reservoir simulated temperature control system as claimed in claim 3, wherein the temperature control unit in the tank comprises three groups of heating pipes, a power supply and a control switch, and the power supply is connected with each heating pipe through the control switch.
6. The marine natural gas hydrate reservoir simulation temperature control system according to claim 5, wherein the data acquisition and processing unit comprises a data acquisition unit, a central processing unit, a memory and a display, each simulation position in the simulation cabin body is provided with a temperature sensor, a second flowmeter is connected to a pipeline of each liquid heat exchange circulation system, one end of the data acquisition unit is connected with the temperature sensor, the first flowmeter and the second flowmeter respectively, the other end of the data acquisition unit is connected with one end of the central processing unit, and the other end of the central processing unit is connected with the memory and the display respectively.
7. The marine natural gas hydrate reservoir simulation temperature control system as claimed in claim 1, wherein the heat exchange tubes are serpentine heat exchange tubes or shell and tube heat exchange tubes distributed in parallel.
8. A method of using the marine natural gas hydrate reservoir simulation temperature control system of any one of claims 1 to 7, comprising the steps of:
s1, natural gas hydrate reservoir environment simulation process: in the simulation cabin main body of the natural gas hydrate reservoir which is constructed in a layered manner, cooling each simulation layer in the simulation cabin main body through the extravehicular temperature control unit; when the temperature data received by the data acquisition and processing unit is lower than a preset value, each simulation layer in the simulation cabin main body is respectively subjected to constant temperature control through the extravehicular temperature control unit;
s2, natural gas hydrate reservoir decomposition process: and heating each simulation layer position in the simulation cabin main body through the temperature control unit in the cabin, and heating and decomposing the natural gas hydrate reservoir in the simulation cabin main body.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010223941.7A CN111561298B (en) | 2020-03-26 | 2020-03-26 | Marine natural gas hydrate reservoir simulation temperature control system and use method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010223941.7A CN111561298B (en) | 2020-03-26 | 2020-03-26 | Marine natural gas hydrate reservoir simulation temperature control system and use method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN111561298A CN111561298A (en) | 2020-08-21 |
| CN111561298B true CN111561298B (en) | 2022-02-22 |
Family
ID=72067687
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010223941.7A Active CN111561298B (en) | 2020-03-26 | 2020-03-26 | Marine natural gas hydrate reservoir simulation temperature control system and use method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111561298B (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113882822B (en) * | 2021-03-11 | 2023-07-18 | 四川大学 | Deep coring high-temperature high-pressure analog test cabin |
| CN113391050B (en) * | 2021-06-28 | 2023-12-12 | 西南石油大学 | Experimental device and method for layering simulation of hydrate formation process |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101553628A (en) * | 2006-10-13 | 2009-10-07 | 埃克森美孚上游研究公司 | Improved method of developing subsurface freeze zone |
| CN101575964A (en) * | 2009-06-05 | 2009-11-11 | 中国石油大学(北京) | Experimental method and device for simulating exploitation of gas hydrates |
| CN102352735A (en) * | 2011-06-29 | 2012-02-15 | 中国科学院广州能源研究所 | Natural-gas hydrate three-dimensional experimental device and three-dimensional simulated experimental method |
| KR20130078495A (en) * | 2011-12-30 | 2013-07-10 | 한국가스공사 | Apparatus for measuring decomposition speed of gas hydrate |
| CN105571647A (en) * | 2016-02-03 | 2016-05-11 | 青岛海洋地质研究所 | Natural gas hydrate exploitation multi-physical field evolution simulation test device and method |
-
2020
- 2020-03-26 CN CN202010223941.7A patent/CN111561298B/en active Active
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101553628A (en) * | 2006-10-13 | 2009-10-07 | 埃克森美孚上游研究公司 | Improved method of developing subsurface freeze zone |
| CN101575964A (en) * | 2009-06-05 | 2009-11-11 | 中国石油大学(北京) | Experimental method and device for simulating exploitation of gas hydrates |
| CN102352735A (en) * | 2011-06-29 | 2012-02-15 | 中国科学院广州能源研究所 | Natural-gas hydrate three-dimensional experimental device and three-dimensional simulated experimental method |
| KR20130078495A (en) * | 2011-12-30 | 2013-07-10 | 한국가스공사 | Apparatus for measuring decomposition speed of gas hydrate |
| CN105571647A (en) * | 2016-02-03 | 2016-05-11 | 青岛海洋地质研究所 | Natural gas hydrate exploitation multi-physical field evolution simulation test device and method |
Also Published As
| Publication number | Publication date |
|---|---|
| CN111561298A (en) | 2020-08-21 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN111561298B (en) | Marine natural gas hydrate reservoir simulation temperature control system and use method | |
| CN102081059B (en) | Forced-convection heat transfer experimental device for strong inner heat source containing porous medium passage | |
| CN101581517B (en) | Heat pump system of single-loop geothermal underground heat exchanger | |
| CN109946103A (en) | A kind of underground heat parameter test system and method based on mid-deep strata ground heat exchanger | |
| CN201032254Y (en) | Energy-saving cold, hot water heater | |
| CN104912532A (en) | Device and method for exploiting seafloor natural gas hydrates through continuously injecting hot seawater | |
| CN101915776B (en) | Measuring method for thermal diffusivity of concrete and testing device | |
| CN101701730A (en) | Two-stage circulation and two-stage water distribution heat supply device | |
| CN105004067A (en) | Heating system making use of both solar energy and air source | |
| CN201944920U (en) | Superconducting solar energy heat-pump hot-water bathing heating system | |
| CN111428346B (en) | Design method of interference-free geothermal heat exchanger comprehensively considering heat exchange-resistance-economic factors | |
| CN101864947A (en) | Method and device for simulating formation temperature in multi-element thermal fluid injected oil extraction three-dimensional simulation test | |
| CN111609574A (en) | Sustainable-utilization cross-season geothermal energy development system | |
| CN101545654A (en) | Solar centralized heat collection household water tank exchange heat supply system | |
| CN207081677U (en) | Rock And Soil thermal property tester for earth-source hot-pump system | |
| CN109840388A (en) | A kind of numerical simulation evaluation method of geothermal system heat wave and degree | |
| CN204386829U (en) | Thermo-electric generation equipment | |
| CN109882118A (en) | A kind of multi-heat source linkage oil well fluid viscosity reduction equipment | |
| CN201607333U (en) | Test device for liquefied natural gas cold-energy adjusting system | |
| CN212806114U (en) | Coaxial combined sleeve type heat exchanger | |
| CN202008414U (en) | Testing device for thermal performance and fluid resistance of liquid-liquid heat exchanger | |
| CN201488125U (en) | Solar-concentrating heat-collecting individual water tank exchange heat supply system | |
| KR20080027180A (en) | An inter-connected geo-thermal hole for preventing effluence of underground water | |
| CN210343307U (en) | Heating simulation experiment device in natural gas hydrate well | |
| CN102759161A (en) | Solar radiation air-conditioner |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |